Tag Archive for: permian

The all-new Hugh Brinson Pipeline supports continued US gas market growth amid global calls for energy diversification.

Energy Transfer’s Hugh Brinson Pipeline Targets Late-2026 Startup

Energies Media reports that Energy Transfer is advancing the Hugh Brinson Pipeline, a new 442-mile project designed to move natural gas from processing facilities in Texas into existing pipeline infrastructure south of the Dallas–Fort Worth area. The company said the pipeline remains on schedule for completion in late 2026, with initial deliveries expected toward the end of 2026.

The article notes that the project is part of a broader buildout of Permian Basin natural gas takeaway capacity aimed at serving growing demand from Texas markets and other downstream customers. Energy Transfer also said the project has progressed through required regulatory processes and that much of the route follows an existing pipeline right-of-way to help limit construction impacts. For additional context on the wider trend, see Ranger coverage on the Permian pipeline buildout and recent capacity additions like the Matterhorn Express expansion.

Energies Media adds that construction began in 2025 and the project is expected to support local manufacturing of steel components. During construction, Energy Transfer said the effort provided nearly 3,100 jobs, with an additional 34 full-time roles associated with the project.

Source: Energies Media
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DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
New Mexicans living and working in the Permian Basin power global energy leadership, driving the basin toward 50% of US oil by 2030.

Permian Partnership Highlights Workforce, Safety, and Community Investment

An opinion column from Tracee Bentley, president and CEO of the Permian Strategic Partnership (PSP), argues that sustaining Permian Basin growth depends on continued investment in the southeast New Mexico communities that support energy development. Bentley writes that if the Permian Basin were a country, it would rank among the world’s top oil producers, and that the region could account for 50% of U.S. oil production by 2030. She says energy companies formed the PSP to collaborate on regional priorities, reporting more than $214 million in direct spending over six years and over $2.3 billion in leveraged collaborative investments.

The piece focuses on workforce development and public services needed to support long-term activity, citing an estimated need for nearly 186,000 additional workers by 2040. Bentley highlights PSP support for career and technical programs in Hobbs, Artesia, and at Southeast New Mexico College, including $15 million in funding this year. She also points to expanded commercial driver training at New Mexico Junior College (with an estimated need for 7,000 new drivers by 2040), regional first-responder training with Eddy County Fire and Rescue, and a $325,000 investment for five cardiac monitors for Carlsbad Fire Department units. Bentley adds that the Permian region represents 9.2% of New Mexico’s population but produces 25.9% of the state’s private-sector GDP, framing these efforts as support for a durable economic base tied to the Permian Basin and ongoing oil and gas royalties.

Source: Albuquerque Journal
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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
Blackcomb Pipeline, a 2.5 Bcf/d Permian–South Texas gas link backed by WhiteWater–Targa joint venture, targets 2026 commissioning.

Blackcomb Pipeline, a 2.5 Bcf/d Permian–South Texas connector, aims for 2026 commissioning

The cooperative nature of the global energy market has been a major driving force for several operations that plan to reach new heights. To develop certain projects, companies often form joint ventures that leverage the expertise of the companies involved to advance projects to reach operational status. The United States has been progressing toward an increased reliance on the gas market as the nation dominates the international gas sector, producing more gas than any other nation. Now, a new conduit known as the Blackcomb Pipeline is reaching towards a 2026 commissioning date.

Joint ventures are often the only way to progress projects towards realization

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Source: Energies Media

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Matterhorn Express expansion is in service, boosting Permian gas throughput and easing regional pipeline bottlenecks.

Matterhorn expansion likely online, boosting Permian gas flows

A key expansion on the Matterhorn Express Pipeline appears to be in service, adding new takeaway capacity for Permian Basin natural gas, according to a recent report from East Daley Analytics.

Pipeline flow data monitored by East Daley show deliveries on Matterhorn rising from a steady 1.65 billion cubic feet per day since June to as high as 1.95 billion cubic feet per day in November, indicating the long-anticipated 0.5 billion cubic feet per day compression expansion may now be operating.

“After consistently delivering about 1.65 billion cubic feet per day since June to the Katy market, Matterhorn flows jumped to as high as 1.95 billion cubic feet per day in November,” East Daley reported, noting the sustained increase “suggests that expansion is now underway or completed.”

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Source: Pipeline & Gas Journal

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U.S. natural gas pipelines are seeing their biggest expansion since 2008, driven by surging LNG, data-center, and manufacturing.

Permian gas wave sparks biggest pipeline buildout since the shale boom

Growing domestic and export demand for Permian’s natural gas is pushing pipeline developers to invest in new pipeline capacity in the U.S. Gulf Coast.

Chemical and manufacturing industries and data centers looking for reliable energy supply drive increased domestic consumption, while the booming LNG exports from the Texas and Louisiana coasts, and at least half a dozen new export plants expected to start up by the end of the decade, are prompting new-built or expanded links to feed gas to the LNG facilities.

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Source: Oil Price

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British oil giant BP on Tuesday reported third-quarter net profit of $2.21 billion, beating analyst expectations.

BP beats third-quarter profit expectations on higher oil and gas production

British oil giant BP on Tuesday reported stronger-than-expected third-quarter profit as higher crude and gas production outweighed a weak oil trading result. Does BP beats third-quarter? Let’s see.

The London-listed oil and gas major posted underlying replacement cost profit, used as a proxy for net profit, of $2.21 billion for July-September period. That beat analyst expectations of $2.03 billion, according to an LSEG-compiled consensus.

BP’s third-quarter net profit came in at $2.3 billion last year and $2.35 billion in the second quarter of 2025.

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Source: CNBC

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ExxonMobil acquired 80,000+ net acres in the Permian Basin from China’s Sinochem, boosting its U.S. oil footprint.

ExxonMobil adds to Permian portfolio with 80,000-acre buy

ExxonMobil adds more than 80,000 net acres in the Permian basin from Chinese state-owned conglomerate Sinochem, the US supermajor revealed Friday in its quarterly earnings report.

The deal was struck sometime in the third quarter, according to them, which did not reveal specific financial terms for the agreement.

However, chief financial officer Kathy Mikells said ExxonMobil made “a couple of acquisitions” in the quarter that totalled $2.4 billion.

“The transaction provides control of drilling locations and opportunities to further deploy our technology to drive greater returns,” ExxonMobil chief executive Darren Woods said on Friday during the company’s third quarter earnings call.

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Source: upstream

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Chevron beat Wall Street estimates of its Q2 profit as Permian output surged and US and worldwide oil and gas output jumped to record highs.

Chevron tops profit estimates on record-high oil and gas output

Chevron Corporation (NYSE: CVX) beat Wall Street estimates of its second-quarter profit as Permian production surged and U.S. and worldwide oil and gas output jumped to record highs. So how does Chevron tops profit?

Chevron reported on Friday adjusted earnings of $3.1 billion, or $1.77 per share, for the second quarter of 2025, compared to adjusted earnings of $4.7 billion, or $2.55 per share, for the same period last year.

The decline was the result of lower realizations due to lower crude oil prices, lower income from upstream and downstream equity affiliates, and an unfavorable fair value adjustment for shares of Hess Corp, Chevron said.

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Source: Oil Price

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Permian oil output tops 6M bpd and may peak at 7.7M by 2035, but plateau—not decline—is expected, per Wood Mac, despite rising costs and challenges.

The Permian is not done yet

Back in 2017, oil production in the Permian stood at 2.2 million barrels daily. Today, the Permian is producing over 6 million barrels daily, accounting for nearly half of the U.S. total. Predictions of a looming peak have lately multiplied.  According to Wood Mackenzie, the Permian is not done yet—not if prices improve.

To be sure, the boom days seem to be over. Production growth in the most prolific shale play in the United States. It has been slowing already as production costs climb higher while oil prices slide lower. Most forecasts for the region agree that growth in production. It is about to slow down further, and Wood Mac is no exception. The consultancy expects output there to add 200,000 barrels daily this year, for a total of 6.6 million barrels daily.

Going forward, growth is about to continue slowing, and the analysts predicted. Until production peaks at 7.7 million barrels daily in 2035. Yet, while many assume that a peak is inevitably followed by a decline, this will not be the case in the Permian. Output of crude oil in the play will plateau at 7.7 million bpd, and this will more than offset production declines in other producing regions in the country—meaning oil demand will be healthy enough to support such a trend.

Companies with big footprints in the Permian, therefore, can enjoy said footprint even with slower growth. Yet companies tend to seek new growth opportunities all the time to sustain their business, and the prospect of peak growth in the Permian is a real one. The gas-to-oil ratio of output there has been on the rise, as has the water-to-oil ratio in the play. Both trends suggest that some formations in the basin are reaching geological constraints, and more drilling isn’t necessarily proportionate to the oil volumes produced.

Indeed, Big Oil executives have predicted that peak oil supply will arrive in the U.S. before 2035. This does not, of course, mean they are right and Wood Mac analysts are wrong. It simply means that nothing is certain until it happens. And it seems that the slowdown in the Permian is already happening. It also seems that the challenges are multiplying: the latest is concern that toxic wastewater in underground reservoirs could leak and that it could affect seismic activity in the area. In response to these risks, the Railroad Commission of Texas has started imposing restrictions on the amount of wastewater disposed of underground until pressure levels subside.

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Source: Oil & Gas 360

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USEDC to deploy dedicated rig on new acreage as part of its 2025 plan to invest up to $1B in US oil and gas projects.

USEDC expands Permian footprint as part of $1B investment

U.S. Energy Development Corporation (USEDC), a Fort Worth-based exploration and production company focused on developing oil and gas projects. It is for itself and its partners. It has acquired ~20,000 net acres in Reeves and Ward Counties, Texas. The position includes a substantial proved producing component and multi-year drilling inventory to supplement the firm’s existing footprint in the area. This landmark transaction marks the largest single acquisition in the company’s 45-year history and significantly expands its total Permian Basin holdings. Let’s learn more about how USEDC expands Permian footprint.

Dedicated Drilling Rig

“This transaction greatly enhances the overall quality and resilience of our portfolio, supplementing our reserves with additional proved producing assets, adding years of multi-bench drilling inventory, and expanding our operated economies of scale,” said Jordan Jayson, CEO and chairman of USEDC. “These factors position USEDC for sustained, efficient growth and reinforce our commitment to delivering long-term value for our partners.”

USEDC plans to run a dedicated drilling rig on the acquired acreage. It is making this acquisition a key component of USEDC’s 2025 plan to invest up to $1 billion in U.S. oil and gas properties. In 2024, the firm deployed about $850 million in operated and non-operated oil and gas projects in the basin. The firm’s team continues to evaluate opportunities that align with its disciplined investment strategy and can deliver value to our partners.

RBC Richardson Barr advised on the process and Willkie Farr & Gallagher LLP advised USEDC on the acquisition.

Increased Citibank, N.A. Credit Facility</strong>

Concurrent with this acquisition, USEDC completed an increase in the borrowing base and commitments. This is under its syndicated revolving credit facility led by Citibank, N.A. It is from $165 million to $300 million. The upsized revolving credit facility provides USEDC with significant financial flexibility to support its continued growth and has a maximum credit amount of $500 million.

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Source: Oil & Gas 360

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